Note: Descriptions are shown in the official language in which they were submitted.
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STRA1GHT-BORE BACK PRESSURE VALVE
[0001] Not used.
BACKGROUND
[0002; This section is intended to introduce the reader to various aspects
of
art that may be related to various aspects of the present invention, which are
described and/or claimed below. This discussion is believed to be helpful in
providing the reader with background information to facilitate a better
understanding of the various aspects of the present invention. Accordingly, it
should be understood that these statements are to be read in this light, and
not
as admissions of prior art.
(0003] As will be appreciated, oil and natural gas have a profound effect
on
modern economies and societies. In order to meet the demand for such natural
resources, numerous companies invest significant amounts of time and money in
searching for and extracting oil, natural gas, and other subterranean
resources
from the earth. Particularly, once a desired resource is discovered 'below the
surface of the earth, drilling and production systems are employed to access
and
extract the resource. These systems can be located onshore or offshore
depending on the location of a desired resource. Further, such systems
generally include a wellhead assembly that is used to extract the resource.
These wellhead assemblies include a wide variety of components and/or
conduits, such as various control lines, casings, valves, and the like, that
are
conducive to drilling and/or extraction operations. In drilling and extraction
operations, in addition to wellheads, various components and tools are
employed
to provide for drilling, completion, and the production of mineral resources.
For
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instance, during drilling and extraction operations seals and valves are often
employed to regulate pressures and/or fluid flow.
[0004] A
wellhead system often includes a tubing hanger or casing hanger
that is disposed within the wellhead assembly and configured to secure tubing
and casing suspended in the well bore. In addition, the hanger generally
regulates pressures and provides a path for hydraulic control fluid, chemical
injections, or the like to be passed through the wellhead and into the well
bore.
In such a system, a back pressure valve is often disposed in the hanger bore
and/or a similar bore of the wellhead. The back pressure valve plugs the bore
to
block pressures of the well bore from manifesting through the wellhead.
[0005]
Typically, the back pressure valve is provided separately from the
hanger, and is installed after the hanger has been landed in the wellhead
assembly. In other words, the hanger is run down to the wellhead, followed by
the installation of the back pressure valve. One resulting challenge includes
installing the back pressure valve into the hanger bore in context of high
pressures in the bore. Accordingly, installation of the back pressure valve
may
include the use of several tools and a sequence of procedures to set and lock
the
seal. Unfortunately, each of the sequential running procedures may consume a
significant amount of time and money. Further, securing the back pressure
valve
generally includes complementary engagement features in the bore itself. The
bore typically includes shoulders, grooves, notches, or similar features that
are
engaged by portions of the back pressure valve. Thus, the design of the bore
is
configured to accommodate a specific back pressure valve design. Typically,
the
back pressure valve and bore are designed specifically for use with one
another,
thereby, adding yet another level of complexity to the overall design of the
wellhead.
BRIEF DESCRIPTION OF THE DRAWINGS
[0006] Various
features, aspects, and advantages of the present invention will
become better understood when the following detailed description is read with
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reference to the accompanying figures in which like characters represent like
parts throughout the figures, wherein:
[0007] FIG. 1
is a block diagram that illustrates a mineral extraction system in
accordance with an embodiment of the present technique;
[0008] FIG. 2
is a block diagram that illustrates a back pressure valve in
accordance with an embodiment of the present technique;
[0009] FIG. 3
is an exploded cross-sectioned view of a back pressure valve
system in accordance with an embodiment of the present technique; and
[0010] FIG. 4A-
4E are cross-sectioned views of the back pressure valve
system in accordance with embodiments of the present technique.
DETAILED DESCRIPTION OF SPECIFIC EMBODIMENTS
[0011] One or
more specific embodiments of the present invention will be
described below. These described embodiments are only exemplary of the
present invention. Additionally, in an effort to provide a concise description
of
these exemplary embodiments, all features of an actual implementation may not
be described in the specification. It
should be appreciated that in the
development of any such actual implementation, as in any engineering or design
project, numerous implementation-specific decisions must be made to achieve
the developers' specific goals, such as compliance with system-related and
business-related constraints, which may vary from one implementation to
another.
Moreover, it should be appreciated that such a development effort might be
complex and time consuming, but would nevertheless be a routine undertaking of
design, fabrication, and manufacture for those of ordinary skill having the
benefit
of this disclosure.
[0012] When
introducing elements of various embodiments of the present
invention, the articles "a," "an," "the," and "said" are intended to mean that
there
are one or more of the elements. The terms "comprising," "including," and
"having" are intended to be inclusive and mean that there may be additional
elements other than the listed elements. Moreover, the use of "top," "bottom,"
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"above," "below," and variations of these terms is made for convenience, but
does not require any particular orientation of the components.
[0013] Certain
exemplary embodiments of the present technique include a
system and method that each addresses one or more of the above-mentioned
inadequacies of conventional sealing systems and methods. As explained in
greater detail below, the disclosed embodiments include a back pressure valve
that can be installed into a straight bore. More specifically, the back
pressure
valve is installed into a portion of a bore that does not include engagement
features to secure the back pressure valve in the bore. Accordingly, the back
pressure valve is secured against the generally smooth/flat walls of the bore,
as
opposed to grooves, shoulders, or similar features that are typically employed
to
secure a back pressure valve, or a similar valve, in a bore. As a result, the
exemplary back pressure valve may be inserted into a large variety of tubing
hangers with varying bore profiles. In certain embodiments, the back pressure
valve includes a friction member that is expanded radially to secure the back
pressure valve into the bore. In some embodiments, the friction member is
moved longitudinally via hydraulic pressure exerted on an outer sleeve, and/or
secured in a locked position via a locking ring that is rotated into position
to block
the outer sleeve in position when the hydraulic pressure is reduced. Before
discussing embodiments of the system in detail, it may be beneficial to
discuss a
system that may employ such a back pressure valve.
[0014] FIG. 1
is a block diagram that illustrates a mineral extraction system 10
including a back pressure valve (BPV) 12 in accordance with embodiments of the
present technique. The
illustrated mineral extraction system 10 can be
configured to extract various minerals and natural resources, including
hydrocarbons (e.g., oil and/or natural gas), or configured to inject
substances into
the earth. In some embodiments, the mineral extraction system 10 is land-based
(e.g., a surface system) or subsea (e.g., a subsea system). In the illustrated
embodiment, the system 10 includes a wellhead 13 coupled to a mineral deposit
14 via a well 16, wherein the well 16 includes a wellhead hub 18 and a well-
bore
20.
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[0015] The
wellhead hub 18 generally includes a large diameter hub that is
disposed at the termination of the well bore 20. The wellhead hub 18 provides
for the connection of the wellhead 13 to the well 16. In some embodiments, the
wellhead 13 includes a connector that is coupled to a complementary connector
of the wellhead hub 18. For example, in one embodiment, the wellhead hub 18
includes a DWHC (Deep Water High Capacity) hub manufactured by Cameron,
headquartered in Houston, Texas, and the wellhead 13 includes a
complementary collet connector (e.g., a DWHC connector), also manufactured
by Cameron.
[0016] The
wellhead 13 typically includes multiple components that control
and regulate activities and conditions associated with the well 16. In some
embodiments, the wellhead 13 generally includes bodies, valves and seals that
route produced minerals from the mineral deposit 14, provides for regulating
pressure in the well 16, and provides for the injection of chemicals into the
well
bore 20 (down-hole). For example, in the illustrated embodiment, the wellhead
13 includes what is colloquially referred to as a christmas tree 22
(hereinafter, a
tree), a tubing spool 24, and a hanger 26 (e.g., a tubing hanger or a casing
hanger). The system 10 may include other devices that are coupled to the
wellhead 13, and devices that are used to assemble and control various
components of the wellhead 13. For example, in the illustrated embodiment, the
system 10 includes a tool 28 suspended from a drill string 30. In certain
embodiments, the tool 28 includes a running tool that is lowered (e.g., run)
from
an offshore vessel to the well 16 and/or the wellhead 13. In other
embodiments,
such as surface systems, the tool 28 may include a device suspended over
and/or lowered into the wellhead 13 via a crane or other supporting device.
[0017] The
tree 22 generally includes a variety of flow paths (e.g., bores),
valves, fittings, and controls for operating the well 16. For instance, in
some
embodiments, the tree 22 includes a frame that is disposed about a tree body,
a
flow-loop, actuators, and valves. Further, the tree 22 generally provides
fluid
communication with the well 16. For example, in the illustrated embodiment,
the
tree 22 includes a tree bore 32. The tree bore 32 provides for completion and
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workover procedures, such as the insertion of tools (e.g., the hanger 26) into
the
well 16, the injection of various chemicals into the well 16 (down-hole), and
the
like. Further, minerals extracted from the well 16 (e.g., oil and natural gas)
are
generally regulated and routed via the tree 22. For instance, the tree 22 may
be
coupled to a jumper or a flowline that is tied back to other components, such
as a
manifold. Accordingly, in such an embodiment, produced minerals flow from the
well 16 to the manifold via the wellhead 13 and/or the tree 22 before being
routed
to shipping or storage facilities.
[0018] The
tubing spool 24 provides a base for the wellhead 24 and/or an
intermediate connection between the wellhead hub 18 and the tree 22.
Typically,
the tubing spool 24 (also referred to as a tubing head) is one of many
components in a modular subsea or surface mineral extraction system 10 that
are run from an offshore vessel and/or a surface installation system. As
illustrated, the tubing spool 24 includes the tubing spool bore 34. The tubing
spool bore 34 connects (e.g., enables fluid communication between) the tree
bore 32 and the well 16. Thus, the tubing spool bore 34 provides access to the
well bore 20 for various completion procedures, worker procedures, and the
like.
For example, components can be run down to the wellhead 13 and disposed in
the tubing spool bore 34 to seal-off the well bore 20, to inject chemicals
down-
hole, to suspend tools down-hole, and/or to retrieve tools from down-hole.
[0019] As will
be appreciated, the well bore 20 may contain elevated
pressures. For instance, in some systems, the well bore 20 may include
pressures that exceed 10,000 pounds per square inch (PSI), that exceed 15,000
PSI, and/or that even exceed 20,000 PSI. Accordingly, mineral extraction
systems 10 typically employ various mechanisms, such as seals, plugs and
valves, to control and regulate the well 16. In some instances, plugs and
valves
are employed to regulate the flow and pressures of fluids in various bores and
channels throughout the mineral extraction system 10. The illustrated hanger
26
(e.g., tubing hanger or casing hanger), for example, is typically disposed
within
the wellhead 13 to secure tubing and casing suspended in the well bore 20, and
to provide a path for hydraulic control fluid, chemical injections, and the
like. The
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hanger 26 includes a hanger bore 38 that extends through the center of the
hanger 26, and that is in fluid communication with the tubing spool bore 34
and
the well bore 20. Unfortunately, if left unregulated, pressures in the bores
20 and
34 can manifest through the wellhead 13. Accordingly, the back pressure valve
(BPV) 12 is often seated and locked in the hanger bore 38 to regulate the
pressure. Valves similar to the illustrated back pressure valve 12 can be used
throughout the mineral extraction system 10 to regulate fluid and/or gas
pressures and flow paths.
[0020] In the
context of the hanger 26, the back pressure valve 12 can be
installed into the hanger 26, or a similar location, before the hanger 26 is
installed
in the wellhead 13, or may be installed into the hanger 26 after the hanger 26
has
been installed in the wellhead 13 (e.g., landed in the tubing spool bore 34).
In
the latter case, the hanger 26 is typically run down and installed into the
subsea
wellhead 13 (or a similar surface wellhead), followed by the installation of
the
back pressure valve 12. During installation of the back pressure valve 12,
pressure in the well bore 20 may exert a force (e.g., a backpressure) on the
lower portion of the back pressure valve 12. Unfortunately, the backpressure
may increase the difficulty of installing the back pressure valve 12. For
example,
the backpressure may resist the installation of the back pressure valve 12.
Although typical embodiments of the hanger bore 38 include shoulders, grooves,
notches, or similar features that are engaged by portions of the back pressure
valve 12, in embodiments of the system 10, the back pressure valve 12 is
disposed in a portion of the hanger bore 38 that is a straight bore.
Accordingly,
the system and methods discussed in greater detail below provide a system and
method including disposing the back pressure valve 12 in the straight hanger
bore 38, and/or a similar straight bore (e.g., a tubing or casing pipe bore).
[0021] FIG. 2
is a block diagram that illustrates an embodiment of the back
pressure valve (BPV) 12 disposed in a bore 40 in accordance with embodiments
of the present techniques. In the illustrated embodiment, the BPV 12 includes
a
body 42, a friction member 44, an outer sleeve 46, a lock ring 48, a plunger
50,
and a seal 52.
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[0022] The
bore 40 includes a straight bore (e.g., a full-bore). A straight bore
can be defined as a bore having an internal diameter including generally
constant
or uniform surfaces that do not include engagement/retention features such as
shoulders, grooves, notches, or the like. For example, in some embodiments,
the internal surface of the bore includes straight or flat walls that are
generally
parallel to a longitudinal axis of the bore. In some embodiments, the bore 40
includes a generally cylindrical bore formed from casing, tubing, or a bore
internal to the system 10, such as the hanger bore 38. For example, in one
embodiment, the bore 40 includes the hanger bore 38, or a similar bore (e.g.,
a
tubing or casing pipe bore), having a generally consistent internal diameter
along
its length.
[0023]
Further, in one embodiment the bore 40 is straight along its entire
length, whereas in other embodiment, the bore 40 is straight along some
portion
but not all of its length. For example, the bore 40 is straight at least in
the portion
of the bore 40 where the BPV 12 is seated, in one embodiment. In such an
embodiment, other portions of the bore 40 may include engagement features that
are configured for securing other valves and tools, for instance.
[0024] The
surface of the bore 40 generally does not include any significant
physical features or preparation, in some embodiments. For example, in one
embodiment, the bore 40 includes a smooth unfinished surface. This includes
the standard finish of the body that forms the bore 40, such as, for example,
the
interior of the casing, the tubing, and the hanger bore 38. However, in other
embodiments, the internal surface of the bore 40 includes a modified surface.
In
other words, the internal surface of the bore 40 includes some form of
preparation of the surface, but still does not include engagement/retention
features, such as shoulders, grooves, notches, or the like. In one embodiment,
the modified surface includes a scored surface, or otherwise coarse finish to
encourage friction (e.g., increase the coefficient of friction) between the
internal
surface of the bore 40 and complementary features of the BPV 12. In another
embodiment, the modified surface includes polishing, smoothing, or otherwise
preparing the surface for contact with the back pressure valve 12.
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[0025] In the
illustrated embodiment, the bore 40 includes a longitudinal axis
54 running the length of the bore 40. In operation, the BPV 12 is located
along
the longitudinal axis 54 and regulates pressures between an upper bore portion
56 and a lower bore portion 58. The upper bore portion (e.g., a downstream and
bore portion) 56 includes a portion of the bore 40 toward an upper end of the
wellhead 13 and the lower bore portion (e.g., a downstream bore portion) 58
includes a portion of the bore 40 that is on an opposite end of the well-head
13.
For example, the lower bore portion 58 includes an end exposed and/or in the
direction of the well-bore 20 and/or the mineral deposit 14, in certain
embodiments.
[0026] The
body 42 of the BPV 12 includes an upper end 60 (e.g.,
downstream end), a lower end 62 (e.g., upstream end), a plunger bore 64, and a
recess 66. The upper end 60 of the body 42 generally is exposed to and faces
the upper bore portion 56 when installed. Similarly, the lower end 62 of the
body
generally is exposed to and faces the lower bore portion 58. Accordingly, when
installed, the lower end of the BPV 12 is exposed to the pressures associated
with the lower bore portion 58. These pressures typically include pressures
from
the well bore 20, the mineral deposit 14, fluids and gases injected down-hole
and
the like. The pressures generally act on the lower end 62 in the direction of
the
arrows 68 (e.g., toward the upper bore portion 56).
[0027] The
plunger bore 64 includes a bore that extends through the length of
the body 42 of the BPV 12. The plunger bore 64 generally includes a path for
the
regulation of pressure between the upper bore portion 56 and the lower bore
portion 58. For example, when opened (e.g., not occluded) fluids and gases on
either side of the BPV 12 can flow back and forth to maintain a balanced
pressure between the upper bore portion 56 and the lower bore portion 58. This
may be particularly useful during installation and removal of the BPV 12 when
the
pressure is balanced to enable moving of the BPV 12 within the bore 40 and
along the longitudinal axis 54 without additional loading to overcome the
longitudinal forces, such as those acting on the lower end 62 of the BPV 12.
When closed (e.g., occluded) the BPV 12 generally occludes the bore to
maintain
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a pressure differential between the upper bore portion 56 and the lower bore
portion 58. More specifically, in an embodiment in which the plunger 50
includes
a unilateral check valve, the BPV 12 is typically configured to retain an
elevated
pressure in the lower bore portion 58.
[0028] As
mentioned briefly above, the plunger 50 is typically employed to
regulate the flow of fluids and gases through the BPV 12. More specifically,
the
plunger 50 includes an open position and a closed position in certain
embodiments. For example, in one embodiment, the plunger 50 includes a
sealing portion (e.g., a bell) that is configured to engage a complementary
sealing surface or feature in the plunger bore 64. In a closed position, the
sealing portion of the plunger 50 engages the sealing surface/feature in the
plunger bore 64 to occlude the plunger bore 64. In an open position, the
sealing
portion of the plunger 50 is urged/located away from the sealing surface of
the
plunger bore 64, thereby enabling fluid and gases to pass through the plunger
bore 64. Certain embodiments of the plunger 50 and the plunger bore 64 are
discussed in more detail below with regard to FIGS. 3 and 4A-4E.
[0029] The
recess 66 generally includes one or more indentations in an
external surface 70 of the body 42. In one embodiment, the recess 66 includes
a
single groove about an external surface (e.g., circumference) 70 of the body
42.
In other embodiments, the recess 66 includes one or more separate recessed
sections about the external surface 70 of the body 42. In the illustrated
embodiment, the recess 66 includes a groove that extends around the
circumference of the body 42 and that includes an upper face 72, a lower face
74
and an internal face 76. The internal face 76 includes an angle (e.g., a
taper)
relative to the longitudinal axis 54, in the illustrated embodiment. For
example,
the internal face 76 includes a smaller diameter proximate the upper face 72
and
the upper end 60 of the body 42, and includes a larger diameter proximate the
lower face 74 and the lower end 62 of the body 24 (e.g., a conical section of
the
body 42). In other words, the internal face 76 includes a taper that increases
in
diameter from the upper face 72 to the lower face 74. Thus, the internal face
76
is oriented at an angle 78 relative to the longitudinal axis 54. As is
discussed in
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greater detail below, the angle 78 may include any angle suitable for
expanding
the friction member 44. For example, in one embodiment, the angle 78 is
between about 5 degrees and 10 degrees. However, in other embodiments, the
angle 78 may be greater than about 10 degrees or less than about 5 degrees.
Further, a height 79 of the recess 66 is defined by the distance between the
upper face 72 and the lower face 74.
[0030] The
friction member 44 generally includes one or more devices that
are employed to secure the BPV 12 to the bore 40. More specifically, in some
embodiments, the friction member 44 includes one or more members (discussed
in more detail below) that are expanded in a radial manner/direction to
contact
the walls of the bore 40, thereby securing the BPV 12 to the bore 40. In
certain
embodiments, an outer surface (e.g., friction surface) of the friction member
44
directly contacts a straight portion of the bore 40, thereby securing the BPV
12 in
the bore without the aid of any engagement/retention features, such as
shoulders,
grooves, notches, or the like.
[0031] In the
illustrated embodiment, the friction member 44 includes a friction
face 80, an internal face 82, an upper face 84, and a lower face 86. The upper
face 84 and lower face 86 are proximate the upper face 72 and lower face 74,
respectively, of the recess 66 in the body 42. As depicted in the illustrated
embodiment, a height 88 (e.g., the distance between the upper face 84 and the
lower face 86) of the friction member 44 is less than the height 79 of the
recess
66. Accordingly, in one embodiment, the friction member 44 is capable of
moving longitudinally (e.g., a long the longitudinal axis 54) relative to the
recess
66 and the body 42 of the BPV 12.
[0032] The
internal face 82 generally includes a profile that is complementary
to the profile of the internal face 72 of the body 42. In the illustrated
embodiment,
for example, the internal face 82 of the friction member 44 includes a taper
that is
complementary to the taper (angle 78) of the internal face 76. In other words,
the
internal face includes a profile (taper) that increases in diameter from the
upper
face 84 to the lower face 86. Accordingly, in one embodiment, movement of the
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friction member 44 in a longitudinal direction (e.g., along the longitudinal
axis 54)
relative to the body 42 and the recess 66 causes the friction member to expand
and/or contract radially. For example, in an embodiment where the friction
member 44 is located proximate the upper face 72 of the recess 66 and urged
toward the lower face 74 of the recess 66, the friction member 44 expands
radially in the direction of the arrows 90. As is discussed below, the urging
force
to displace the friction member 44 can be provided downward on the friction
member 44(e.g., from the outer sleeve 46) or upward on the body 42 (e.g., the
pressure acting on the lower end 62 of the body 42), in certain embodiments.
In
one embodiment, force may be applied in the opposite direction to urge the
friction member 44 upward (e.g., toward the upper face 72 of the recess 66 and
urge the friction member inward, in a direction opposite the arrows 90.
Further, it
will be appreciated that although the illustrated embodiment includes urging
the
friction member downward (e.g., toward the lower face 74 and toward the lower
bore portion 58) to expand the friction member radially, other embodiments
include a similar configuration wherein urging the friction member 44 in an
upward direction expands the friction member 44 radially. For example, the
taper
can be reversed in one embodiment such that the diameter is larger proximate
the upper face 72 of the recess 66 and smaller proximate the lower face 74. In
any of the embodiments, expanding the friction member 44 causes the friction
face 80 of the friction member 44 to contact the internal surface of the bore
40.
[0033] The
friction face 80 includes the face located on the outside of the
friction member 44. Generally, the friction face 80 contacts the walls of the
bore
40 when the friction member 44 is expanded in a radial direction, represented
by
the arrows 90. In certain embodiments, the friction face 80 includes one or
more
surface features conducive to securing the friction member 44, and, thus, the
BPV 12 to the bore 40. Generally, the friction face 80 includes a surface that
provides a coefficient of friction sufficient to secure the BPV 12 in the bore
40 in
light of the pressures experienced across the BPV 12. For example, in one
embodiment, the friction face 80 includes a coarse finish. The coarse finish
is
provided by scoring, or sanding the friction face 80, in one embodiment. In
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another embodiment, the coarse finish is provided by coating the friction face
80
with a composite material. For example, the friction face 80 includes a
coating of
a material having a hardness that is less than the hardness of the surface of
the
bore 40, in one embodiment.
[0034] In
other embodiments, the surface features include indentations and/or
patterns of indentations in the friction face 80. In one embodiment, the
friction
face 80 includes a plurality of grooves that provide localized areas of high
surface contact forces when the friction member 44 is expanded radially
against
the surface of the bore 40. These localized areas of force enable the friction
member 44 to bite into the interior of the bore 40. For example, in one
embodiment, the indentations form rows and/or columns of teeth.
[0035] In some
embodiments, the friction face 80 includes a generally flat
and/or smooth surface. For example, in one embodiment, the friction face 80
includes an unfinished or polished surface. In such
an embodiment, the
increased contact area between the friction face 80 and the surface of the
bore
40 provides the friction to secure the friction member 44 and the BPV 12 to
the
bore 40.
[0036] The
friction face 80, in some embodiments, includes any combination
of the surface features discussed above. For example, in one embodiment, the
friction face 80 includes teeth like features in one region, a smooth finish
in other
regions, and a coating over at least a portion of the regions. In another
embodiment, the friction face 80 includes a combination of recesses (e.g.,
teeth
and grooves) and a coating, for example.
[0037]
Further, the friction face 80 includes a profile that is conducive to
generating a friction between the friction member 44 and the bore 40. In one
embodiment, the friction face 80 includes a profile that is similar to the
profile of
the bore 40. For example, in the illustrated embodiment, the profile of the
friction
face 80 includes a surface that is in generally parallel to the surface of the
bore
40. In other words, the surface of the friction face 80 includes at least a
portion
that is parallel to the longitudinal axis 54 (e.g., cylindrical exterior).
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[0038] The
friction member 44 is formed from one or more devices that are
capable of being expanded radially, as discussed above. In some embodiments,
the friction member 44 includes one or more rings, one or more segments, one
or
more locking dogs, or a combination thereof. For example, in one embodiment,
the friction member 44 includes a C-ring that is positioned in the recess 66.
In
another embodiment, the C-ring includes one or more segments along its
exterior
that are configured to contact the surface of the bore 40. In such
embodiments,
the recess 66 may include a groove that extends around circumference of the
body 42. In another embodiment, the friction member 44 includes one or more
locking segments that are positioned in one or more recesses 66 about the
circumferences. For example, in one embodiment, the segments are disposed
about a single groove forming the recess 66. In another embodiment, the recess
66 includes a plurality of separate indentations that are configured to accept
one
or more of the segments forming the friction member 44. For example, the
friction member 44 is formed form several segments that are not joined to one
another in one embodiment. In another embodiment, the segments are coupled
to one another by a common member. For example, in one embodiment, the
friction ring 44 includes a plurality of segments coupled to a common ring. It
will
be appreciated that the friction member 44 may includes any mechanism or
device configured to expand radially to provide a securing/friction force
between
the BPV 12 and an internal surface of the bore 40.
[0039] The
outer sleeve 46 generally includes a device or mechanism that
exerts a force on the friction member 44. More
specifically, in certain
embodiments, the outer sleeve 46 exerts a longitudinal force (e.g., a force
parallel to the longitudinal axis 54) on the friction member 44 that causes
the
friction member 44 to expand radially. For
example, in the illustrated
embodiment, urging the outer sleeve 46 in the direction of arrows 92 generates
an axial load on at least a portion of the upper face 84 of the friction
member 44.
The axial load urges the friction member 44 in the direction of the arrows 92,
thereby causing radial expansion of the friction member 44, as discussed
above.
Although the outer sleeve 46 is located above the friction member 44 in the
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illustrated embodiment, all or at least a portion of the outer sleeve 46 may
be
located below the friction member 44 in other embodiments. For example, in an
embodiment where an axial load is delivered to the lower face 86 of the
friction
member 44, at least a portion of the outer sleeve may be located below the
friction member 44. For example, as discussed in greater detail below with
regard to FIGS. 3-and 4A-4E, a portion of the outer sleeve 46 is located below
the friction member 44 to provide a force in the direction of arrows 94 to
enable
the friction member 44 to contract radially. In another embodiment, for
example,
the embodiment in which the taper is reversed, the axial force in the
direction of
the arrows 94 is employed to expand the friction member 44 radially.
[0040] The
axial force provided by the outer sleeve is generated by hydraulic
loading in some embodiments. For example, although not depicted in FIG. 3, as
discussed in greater detail below with regard to FIGS. 3 and 4A-4E, the BPV 12
includes a hydraulic port that terminates in a chamber proximate the outer
sleeve
46 such that energizing the hydraulic port and chamber exerts a force on the
outer sleeve 46 in the direction of the arrows 92, thereby providing the axial
loading on the friction member 44. Other embodiments may include similar
forms of loading. For example, in one embodiment, the outer sleeve 46 is
threaded to the body 42, such that rotation of the outer sleeve 46 generates
the
axial force in the direction of the arrows 92.
[0041] The
lock ring 48 secures the position of outer sleeve 46 and, thus, the
position of the friction member 44, in certain embodiments. In one embodiment,
the lock ring 48 is positioned against the outer sleeve 46 to block the outer
sleeve 46 from moving upward (e.g., in the opposite direction of the arrows
92).
For example, in one embodiment, the lock ring 48 is threaded to the body 42
such that rotation of the lock ring 48 urges the locking ring downward (e.g.,
in the
direction of the arrows 96), and toward the outer sleeve 46. In another
embodiment, the lock ring 48 is urged into movement via a hydraulic
arrangement similar to that discussed above with regard to the outer sleeve
46.
Accordingly, the lock ring 48 is urged/moved along the longitudinal axis 54
until it
abuts the outer sleeve 46, thereby securing the outer sleeve 46 in a position.
In
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one embodiment, the outer sleeve 46 is secured in a locked position (e.g., a
position holding the friction member 44 in the radially expanded position),
for
instance. In one embodiment, hydraulic pressure is employed to urge the outer
sleeve 46 into engagement with the friction member 44. The lock ring 48 is
rotated until it is proximate or abutting the outer sleeve 46, and the
hydraulic
pressure is released. With the hydraulic pressure is released, the outer
sleeve
46 is blocked from moving a significant longitudinal distance by the lock ring
48.
Thus, the friction member 44 is held in position (e.g., an expanded position)
via
the outer sleeve 46 and the lock ring 48.
[0042] In some
embodiments, the BPV 12 includes one or more additional
seals that block/regulate the pressures between the lower bore portion 58 and
the upper bore portion 56. For instance, in the illustrated embodiment, the
BPV
12 includes a seal 52 disposed between the body 42 and the internal surface of
the bore 40. In one embodiment, the seal 52 includes a mechanical (e.g., MEC)
seal. In another embodiment, the seal 52 includes an elastomer seal or similar
seal.
[0043] The
seal 52, in some embodiments, is compressed within a region
between the body 42 and the surface of the bore 40. For example, in the
illustrated embodiment, the seal 52 is disposed between a tapered surface 98
of
the body 42 and the internal surface of the bore 40. More specifically, the
tapered surface 98 includes a diameter that increases proximate the lower end
62 of the body 42. Accordingly, urging the seal 52 toward the lower end 62 and
into engagement with the tapered face 98 (e.g., urging the seal in the
direction of
arrows 100) compresses (e.g., seats) the seal 52 between the tapered face 98
and the internal surface of the bore 40. In the seated position, the seal 52
provides a fluid seal that blocks fluids and gases from passing the BPV 12.
[0044] In one
embodiment, the seal 52 is seated by a member that is urged in
the direction of the arrow 100 to compress and seat the seal 52. For example,
although not depicted in FIG. 2, as discussed in further detail with regard to
FIGS.
3 and 4A-4E, in one embodiment, the outer sleeve 46 includes an extension that
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protrudes below the friction member 44 and into contact with the seal 52.
Accordingly, the outer sleeve 46 is urged in the direction of the arrows 92 to
seat
the seal 52, in one embodiment. Further, as is discussed below, in one
embodiment, the outer sleeve 46 includes a window such that movement of the
outer sleeve 46 in the direction of the arrow 92, first, seats the seal 52,
and,
second, urges the friction member 44 into radial expansion.
[0045]
Further, as discussed in detail with regard to FIGS. 3 and 4A-4E, the
BPV 12 is disposed (e.g., run) into position within the bore and/or installed
via
one or more running tools. More specifically, in certain embodiment, a running
tool couples to the upper end 60 of the BPV 12 to provide operation of the BPV
12 during installation and retrieval, among other operations. For example, as
discussed below, a running tool urges the plunger 50 to an open position, runs
the BPV 12 to the desired location, provides hydraulic pressure to engage the
outer sleeve 46 to seat the seal 52 and radially expand the friction member 44
into contact with the bore 40, rotates the lock ring 48 to abut the outer
sleeve 46,
releases hydraulic pressure, urges the plunger 50 into a closed position, and
disconnects itself from the BPV 12 before being extracted from the bore 40.
[0046]
Although the previously discussed embodiments include operation of
the friction member 44 as relying on longitudinal forces provided via the
outer
sleeve 46, the lock ring 48, and the body, it is worth noting that pressure
acting
on the BPV 12 provides for urging the friction member 44 into an expanded
position. For example, in one embodiment, the pressure in the lower bore
portion 58 acts on the lower end 62 of the body 42 of the BPV 12. Such a
loading provides for urging the body 42 upward relative to the friction member
44.
The upward movement along the longitudinal axis 54 provides for increasing the
radial force (e.g., in the direction of arrows 90) acting on the friction
member 44.
Accordingly, as the pressure in the lower bore portion 58 increases, the
radial
expansion of the friction member 44 increases, thereby providing increased
friction between the friction face 80 and the bore 40. In other words, as the
pressure in the lower portion increases 58, the illustrated embodiment of the
BPV
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12 is secured even tighter into the bore 40, helping to prevent the BPV 12
from
becoming dislodged.
[0047] Turning now to FIGS. 3 and 4A-4E, one embodiment of a BPV system
110 is depicted. More
specifically, the illustrated embodiments include an
installation sequence of a BPV system 110 including one embodiment of the BPV
12 and one embodiment of a back pressure valve (BPV) running tool 112. The
BPV 12 includes features similar to those discussed above with regard to the
BPV 12 of FIG. 2. For example, as depicted, the BPV 12 includes one
embodiment of the body 42, the friction member 44, the outer sleeve 46, the
lock
ring 48, the plunger 50, and the seal 52.
[0048] In the
illustrated embodiment, the body 42 includes a lower body
portion 120 and an upper body portion 122. The lower body portion 120 includes
the plunger bore 64. The plunger bore 64 includes a plunger bore sealing face
124. In the illustrated embodiment, the plunger bore sealing face 124 includes
a
taper between a lower plunger bore portion 126 and an upper plunger bore
portion 128. The taper 124 includes an angled face (e.g., conical shaped face)
that extends between the lower plunger bore portion 126 and the upper plunger
bore portion 128. The taper 124 is shaped complementary to a plunger sealing
face 130. In the illustrated embodiment, the upper plunger bore portion 128 is
narrower (e.g., has a smaller diameter) than the lower plunger bore portion
126.
[0049] The
lower body portion 120 also includes a holding ring 132 coupled to
the lower end 62 of the lower body portion 120. The holding ring 132 is
coupled
to the lower body portion 120 via mechanical fasteners (e.g., bolts) 134. The
holding ring 132 extends into the lower plunger bore portion 126 and includes
a
stem bore 135 that extends through the center of the holding ring 132 along
the
longitudinal axis 54. As is discussed in further detail below, the holding
ring 132
retains the plunger 50 in the plunger bore 64.
[0050] The
plunger 50 includes a stem 136, a bell 138, and a spring 140. The
stem 136 is coupled to and extends downward form the bell 138. In the
illustrated embodiment, the stem 136 is aligned along the longitudinal axis 54
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and extends into the stem bore 135 of the holding ring 132. Further, the
spring
140 is disposed around the stem 136 and is retained between the bell 138 and
the holding ring 132. Accordingly, as the plunger 50 is urged toward the
holding
ring 132 (e.g., where the plunger 50 is urged to an open position), the spring
140
provides a biasing force urging the plunger 50 to a closed position (e.g., the
sealing face 130 of the bell 138 into contact with the plunger bore sealing
face
124.
[0051] In the
illustrated embodiment, the bell 138 includes a seal 142 (e.g.,
annular seal) and a bell stem 144. The seal 142 generally includes a seal
configured to seal against the plunger bore sealing face 124. The bell stem
144
includes a protrusion extended from the bell 138 in the direction of the upper
plunger bore portion 128. In operation, the bell stem 144 enables a tool or
similar device to engage the plunger via the upper plunger bore portion 128.
For
example, as is discussed in further detail below, in one embodiment, the
running
tool 112 is threaded into a thread 146 of the upper plunger bore 128 and
depresses the plunger 50 via the bell stem 144, thereby urging the plunger 50
toward an open position.
[0052] The
upper body portion 122 includes a cylindrical ring that is coupled
to the lower body portion 120. In the illustrated embodiment, the upper body
portion 122 includes a cylindrical ring that is disposed about an external
diameter
of an upper end 148 of the lower body portion 120. The upper body portion 122
is coupled to the lower body portion 120 via a mechanical fastener (e.g., a
bolt)
150.
[0053]
Further, the upper body portion 122 includes a hollow center 152. As
is discussed in further detail below, the hollow center 152 is capable of
receiving
at least a portion of the BPV running tool 112. An upper body hydraulic port
154
extends from an interior surface of the hollow center 152 and extends through
the upper body portion 122 to a lower end 156 of the upper body portion 122.
The upper body hydraulic port 154 terminates into a cavity 158 formed between
the upper body portion 122, the lower body portion 120 and the outer sleeve
46.
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The cavity 158 is sealed via three annular seals 160, 162 and 164 disposed
between the upper body portion 122, the lower body portion 120 and the outer
sleeve 46.
[0054] The
friction member 44 includes, in the illustrated embodiment,
segments disposed in the recess 66 of the lower body portion 120. The friction
member 44 is coupled to the body 42 via fasteners (e.g., bolts) 166. The
fasteners 166 are passed through through-holes 166. The through-holes 166
includes slots that enable the friction member 44 to move relative to the
fasteners
166 and the body 42. More specifically, the friction member 44 is capable of
being moved axially up and down in the recess to contract and expand,
respectively, the friction member 44. For example, in the illustrated
embodiment,
the friction member 44 is in the radially contracted (e.g., up) position, and
may be
slid/urged into the radially expanded (e.g., down) position, as discussed
previously with regard to FIG. 2.
[0055] The
outer sleeve 46 includes a cylindrical body 170 disposed around
the exterior of the body 42. In the illustrated embodiment, the outer sleeve
46
extends both above and below the friction member 44. For example, the body
170 of the outer sleeve 46 includes windows 172 that span the region proximate
the friction member 44. More specifically, the windows 172 include cutouts
through the body 170 that enable the outer sleeve 46 to slide in a
longitudinal
direction (e.g., parallel to the longitudinal axis 52) relative to the body 42
and/or
the friction member 44. For example, the windows 172 include an upper window
face 174 and a lower window face 176 that are separated by a distance that is
greater than the height 88 of the friction member 44. Accordingly, in the
illustrated embodiment, the outer sleeve 46 can be moved longitudinally
downward for a distance before the upper face 174 of the body 170
contacts/engages the upper face 84 of the friction member 44. As is discussed
below, this longitudinal movement can be employed to urge the seal 52 into a
seated position. Further, the outer sleeve 46 can continue to move in the
longitudinal downward direction to engage the upper face 84 of the friction
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member 44 and to cause the friction member to move downward in the recess 66
and expand radially, as discussed above with regard to FIG. 2.
[0056] In the
illustrated embodiment, the seal 52 includes a MEC seal 52
disposed at a lower end 180 of the outer sleeve 46. As discussed previously,
urging the outer sleeve 46 downward displaces the seal 52 downward along the
longitudinal axis 54. As the seal 52 is urged downward, it is compressed
between the tapered face 98 of the body 42 and the bore 40 until it is
proximate
and/or disposed in a seated position.
[0057] An
upper end 182 of the outer sleeve 46 includes shear pin holes 184
that support shear pins 186 disposed between the outer sleeve 46 and the lock
ring 48. Further, the upper end 182 includes a recess 188 that houses bearings
190 disposed between the outer sleeve 46 and the lock ring 48. Similarly, the
lock ring 48 includes complementary shear pin holes 192 configured to support
the shear pins 186 and a complementary bearing groove 194 that supports and
houses the bearings 190.
[0058] The
lock ring 48 includes a cylindrical ring that is disposed about the
upper portion 122 of the body 42. In the illustrated embodiment, the lock ring
48
includes threads 196 about the internal diameter that are complementary to
external threads 198 about the external diameter of the upper body portion
122.
Accordingly, rotation of the lock ring 48 relative to the upper body portion
122
imparts a longitudinal movement of the lock ring 48 along the longitudinal
axis 54.
For example, rotating the lock ring 48 may secure the outer sleeve 46 in a
locked
position as discussed previously with regard to FIG. 2. Further, in the
illustrated
embodiment, the lock ring 48 includes axial slots 199. In operation, the slots
199
are engaged by complementary protrusions of the BPV running tool 112. The
slots 199 transfer rotational torque from the BPV running tool 112 to the lock
ring
48. Accordingly, rotation of the BPV running tool 112 imparts a rotation of
the
lock ring 48 via the slots 199, in one embodiment.
[0059] Turning
now to the BPV running tool 112, as illustrated in FIG. 3, the
BPV running tool 112 includes a lower tool portion 200 and an upper tool
portion
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202. The lower tool portion 200 includes a stem 204, a threaded portion 206, a
hydraulic port 208, seals 210 and 212, a check valve 214, a groove 216, and
slots 218. The
upper body portion 202 includes a recess 220, internal
protrusions 222, a port 224, a check valve stem 226, and external protrusions
228.
[0060] The
stem 204 includes a protrusion along the longitudinal axis 54 and
extending downward. In operation, the stem 204 engages the bell stem 144. In
other words, as the BPV tool 112 is lowered into and/or engaged with the BPV
12,
the stem 204 engages the bell stem 144, thereby urging the plunger 50 into the
open position.
[0061] The threaded portion 206 includes an external thread that is
complementary to the thread 146 of the upper plunger bore 128. Accordingly,
rotation of the lower portion 200 of the BPV running tool 112 relative to the
body
42 generates longitudinal movement of the lower portion of the BPV running
tool
112 relative to the body 42 and the BPV 12. For example, prior to deploying
the
BPV 12 and the BPV running tool 112, the BPV running tool 112 is coupled to
the
BPV 12 via the threaded portion 206 and the thread 146 of the upper plunger
bore 128. When threaded together, the longitudinal movement of the lower
portion 200 of the BPV running tool 112 relative to the body 42 and the BPV 12
causes the stem 204 to urge the plunger 50 into an opened position.
[0062] The
hydraulic port 208 includes a bore that extends from an upper end
230 of the lower portion 200 of the BPV running tool 112 and terminates in the
external diameter of the lower body portion 200. In the illustrated
embodiment,
the hydraulic port 208 includes an L-shape that enables the port 208 to align
with
the hydraulic port 154 in the upper body portion 122 of the body 42 of the BPV
12.
When the BPV 12 and the BPV running tool 112 are assembled, the two seals
210 and 212 flank the hydraulic ports 208 and 154 enabling pressurized fluid
to
pass between the ports 208 and 154. For example, as is discussed in further
detail below, hydraulic fluid is injected into the cavity 158 via the
hydraulic ports
154 and 208 to urge the outer sleeve 46 into a locked position.
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[0063]
Further, the check valve 214 is disposed in the hydraulic port 208.
More specifically, the check valve 214 is disposed in the upper end 230 of the
lower portion 200 of the BPV running tool 112. The check valve 214 helps to
block hydraulic fluid from reversing in direction once injected into the
hydraulic
port 208. In other words, the check valve helps to maintain pressure within
the
hydraulic port 208. In operation, the check valve is opened via the check
valve
stem 226 that protrudes from the upper portion 202 of the BPV running tool
112.
In the illustrated embodiment, the check valve stem 226 is disposed in the
port
224 of the upper portion 202, and includes a port 232 that extends through its
length. Accordingly, the check valve stem 226 engages the check valve 214
(e.g., depresses or moves the check valve 214 along the longitudinal axis 54,
and enables hydraulic fluid to pass from the port 224 to the hydraulic port
208, in
the illustrated embodiment.
[0064] The
groove 216 of the lower portion 200 includes an annular recess in
the circumference that is engaged by the internal protrusions 222 of the upper
portion 202. The slots 218 include a plurality of depressions that extend
upward
from the groove 216 and are spaced around the circumference of the upper end
230 of the lower portion 200 of the BPV running tool 112. The slots 218 are
sized such that the internal protrusions 222 engage the slots 218 when the
upper
portion 202 and the lower portion 200 are moved longitudinally relative to one
another. For example, as is discussed in further detail below, the protrusions
222 include stems that extend inward into the groove 216 enabling the upper
portion to rotate about the lower portion 200 in the illustrated position.
Upward
axial movement of the upper portion 202 causes the internal protrusions 222 to
engage the slots 218, thereby enabling the rotational torque of the upper
portion
202 to rotate the lower portion 200.
[0065] The
external protrusions 228 include pins or similar extensions that
protrude from the external diameter of the upper portion 202. As discussed
previously, the external protrusions 228 are configured to engage the slots
199 of
the locking ring 48. Accordingly, rotation of the upper portion 202 translates
into
rotation of the locking ring 48, in certain embodiments.
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[0066] It is
further noted that the upper portion 202 includes an attachment
thread 234. The attachment thread 234 includes an internal thread that is
couplable to casing, tubing, or a similar device employed to run the BPV 12
and/or the BPV running tool 112 into the bore 40. For example, casing is
threaded into the attachment thread 234 to support the BPV running tool 112
and
to provide for the delivery of hydraulic fluid in one embodiment.
[0067] Turning
now to FIG. 4A-4C a sequence of installing the BPV 12 is
illustrated. FIG. 4A depicts the BPV 12 and the BPV running tool 112 assembled
to one another and disposed in the straight bore 40. In the
illustrated
embodiment, the check valve stem 226 has engaged the check valve 214, the
external protrusions 222 are located in the groove 216, the hydraulic port 208
of
the BPV running tool 112 is aligned with the hydraulic port 154 of the body 42
of
the BPV 12, the shear pins 186 are intact (e.g., un-sheared), the stem 204 of
the
BPV running tool 112 has engaged the bell stem 144 of the plunger 50 (e.g.,
urged/depressed the plunger 50 to the open position), the friction member 44
is
disposed atop the recess 66 in the radially contracted position, a distance
240
exists between the upper face 84 of the friction member 44 and the upper
window face 174, and the seal 52 is engaged by the taper 98 of the body 42. In
other words, the BPV 12 is lowered into the bore 40 in a pre-landing position.
[0068] FIG. 4B
depicts the BPV system 10 after hydraulic loading of the BPV
system 110. In the illustrated embodiment, hydraulic fluid is injected into
the
cavity 158 via the hydraulic ports 208 and154. As hydraulic fluid is injected
into
the cavity 158, the increase in pressure and volume causes a longitudinal
downward force on the outer sleeve 42 in the direction of the arrows 92. The
resulting downward force and movement of the outer sleeve 46 shears the shear
pins 186, and urges the outer sleeve 46 downward in the direction of the
arrows
92 into engagement with the friction member 44. In other words, the downward
movement of the outer sleeve 46 eliminates the distance between the upper face
84 of the friction member 44 and the upper window face 174 until the upper
window face 174 engages the upper face 84 of the friction member 44. The
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movement of the outer sleeve 42 creates a gap 160 between the lock ring 42 and
the outer sleeve 46.
[0069] In the
illustrated embodiment, the outer sleeve 46 continues to urge
the friction member 44 downward, creating a gap 242 between the body 42 and
the friction member 44 and radially expanding the friction member in the
direction
of the arrows 90. The radial expansion causes the friction face 80 of the
friction
member 44 to engage the internal diameter of the bore 40. Further, the seal 52
is driven longitudinally beyond the taper 98 in the body 42 into a seated
position.
In other words, the seal is compressed between the body 42 of the BPV 12 and
the bore 40. With the cavity 158 pressurized and the outer sleeve 46 urged
into
the engage position, the BPV running tool 12 is moved up such that the check
valve 214 is disengaged by the check valve stem 226. Accordingly, FIG. 4B
depicts the BPV system 110 wherein the BPV 12 has been hydraulically
pressurized, and the BPV running tool 112 is hydraulically disengaged from the
BPV valve12.
[0070] FIG. 4C
depicts the lock ring 48 rotated into a locked position. For
example, with the BPV 12 hydraulically pressurized, and the BPV running tool
112 hydraulically disengaged from the BPV valve12, the upper portion 202 of
the
BPV running tool 112 is rotated. Rotation of the upper portion 202 of the BPV
running tool 112 is provided via rotation of the casing, tubing, or other
device
coupled to the attachment threads 234, in one embodiment. Accordingly,
rotational torque generated by rotating the upper portion 202 of the BPV
running
tool 112 is transferred to the slots 199 of the locking ring 48 via the
external
protrusions 228. The resulting rotation of the lock ring 48 about the threads
196
and 198 causes the locking ring 48 to move longitudinally downward in the
direction of the arrows 96. The rotation is continued until the lock ring 48
is
proximate or engages the outer sleeve 46. In other words, the gap 160 is
reduced and/or eliminated. Accordingly, the illustrated embodiment includes
the
lock ring 48 moved into a locked position. In the locked position, the lock
ring 48
abuts the outer sleeve 46, thereby securing the outer sleeve 46 and the
friction
member 44 in the radially expanded position.
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[0071] FIG. 4D
depicts the upper portion 202 of the BPV running tool 112
moved upward such that the internal protrusions 222 are disengaged from the
groove 216 and have engaged the slots 218 located above the groove 216. In
other words, once the lock ring 48 is disposed in the locked position, the
upper
portion 202 of the BPV running tool 112 is retracted upward such that the
external protrusions 220 disengage the slots 199 of the lock ring 48 and the
internal protrusions 222 engage the slots 218 of the lower portion 200 of the
BPV
running tool 112. With the internal protrusions 222 engaged in the slots 218,
the
upper portion of the BPV running tool 112 is rotated, for example, via
rotation of
the casing, tubing, or other device coupled to the attachment threads 234,
causing rotation of the lower portion 200 of the BPV running tool 112 that
disengages the threaded portion 206 of the lower portion of the BPV running
tool
112 to disengage threads 146 in the body 42 of the BPV 12. Accordingly,
rotation of the BPV running tool 112 longitudinally disengages the BPV running
tool 112 from the BPV 12. In one embodiment, once the BPV running tool 112 is
disengaged from the BPV 12, the BPV running tool 112 is retrieved/extracted
(e.g., retrieved to a vessel in a subsea system 10).
[0072] FIG. 4E
depicts an embodiment wherein the BPV 12 is installed in the
straight bore 40 and the BPV running tool 112 is disengaged and retrieved from
the bore 40. More specifically, the friction member 44 is radially expanded
into
engagement with the internal surface of the bore 40, the lock ring 48 is set
in the
locked position, the seal 52 is seated, and the BPV running tool 112 is
retrieved
from the bore 40.
[0073] As
discussed above with regard to FIG. 2, the embodiments discussed
with regard to FIGS. 3 and 4A-4E may include any combination or variation of
features. For example, the embodiments may include various configurations of
the friction member 44 (e.g., a C-Ring, segments, and/or locking dogs).
Further,
the friction face 80 may include any variety or combination of surface
finishes
(e.g., scoring, grooves, teeth, etc.). In addition, the seal 52 may include a
MEC
seal and/or a LS seal. Further, although not depicted, retrieval of the tool
may
generally include the BPV running tool 112 being lowered to the BOV 12,
rotating
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the BPV running tool 112 to back-off the lock ring 48 and relieve the
longitudinal
force holding the outer sleeve 46 and the friction member 44 in place, and
extraction of the BPV 12 and the BPV running tool 112 via the bore 40.
[0074] While the
invention may be susceptible to various modifications and
alternative forms, specific embodiments have been shown by way of example in
the drawings and have been described in detail herein. However, it should be
understood that the Invention Is not intended to be limited to the particular
forms
disclosed. Rather, the invention is to cover all modifications, equivalents,
and
alternatives falling within the scope of the invention as defined by the
following
appended claims.
